Exploration Drilling in Indonesia in 2022

Drilling by Pertamina Hulu Energy at Offshore North West Java – Photo by Rick Patenaude

The year 2022 has been quite an active and eventful year for the oil and gas industry in Indonesia, especially in drilling.

Oil and gas operators drilled 760 development wells in 2022. This is slightly below its target of 790 wells, but it is a big increase from 480, the number of development wells drilled in 2021. We expect to see even higher drilling activities as the target of development drilling in 2023 is set at 991 wells.

In exploration drilling, oil and gas operators in Indonesia spudded 30 exploration wells in 2022 compared to 28 wells in 2021.

Out of the 27 exploration wells which were completed in 2022, 22 of them tested hydrocarbon resulting in an 81% success ratio in exploration drilling.

Here are the 22 exploration wells that tested hydrocarbon.

WELL NAMEOIL OR GASOPERATOR
Reentry TDE C-1X LSWGasPertamina Hulu Mahakam
MPT-1XGasPertamina Hulu Mahakam
Camelia – 001GasPertamina EP
Kenanga – 001GasPertamina EP
SGET – 001Oil and gasPertamina EP
SA S-1Oil and gasSele Raya Belida
GASOP D South – 1GasSele Raya Belida
JTB – 2X             GasPHE Ogan Komering
Flamboyan – 1XGasMedco
Timpan – 1GasHarbour Energy, Mubadala, BP
NSO – R2Oil and gasPHE – North Sumatra Offshore
NSO – S2GasPHE – North Sumatra Offshore
Anambas – 2XGasKUFPEC
Nuri – 1XOilBumi Siak Pusako (BSP)
SRT – 1XOil and gasPHE Jambi Merang
Wilela – 001GasPertamina EP
GQX – 1Oil and gasPHE – Offshore North West Java
Bajakah – 1Oil and gasPertamina EP
Kolibri – 001GasPertamina EP
Phoenix – 1XGasPertamina Hulu Sanga Sanga
Markisa – 001GasPertamina EP
Kembo – 001Oil and gasPertamina EP

Locations of the 22 discovery wells in 2022. Graphic provided by SKK Migas.

We expect to see a huge increase in exploration drilling in 2023 with a target of 57 wells as Indonesia is serious in its intention to meet its targets of producing 1 million barrels of oil per day and 12 billion SCF of gas per day by 2030.  

Here are synopses of oil and gas production, field development, and exploration activities in Indonesia in 2022, and what we can expect to see in 2023, according to SKK Migas.

This post is adapted by LDI Training from information provided by SKK Migas.

Jamin Djuang

Top Oil Producers in Indonesia in 2022

The total average daily oil and condensate production volume from all the oil producers in Indonesia in 2022 amounts to 612,712 barrels.

Here are the top 15 oil producers in Indonesia and their average daily oil and condensate production volume in barrels in 2022.

OIL OPERATORSAVERAGE BPD IN 2022
ExxonMobil Cepu Ltd165,906
Pertamina Hulu Rokan159,254
Pertamina EP70,157
Pertamina Hulu Energi ONWJ27,584
Pertamina Hulu Mahakam25,091
Pertamina Hulu Energi OSES19,638
PetroChina International Jabung Ltd15,610
Medco E&P Natuna10,255
Pertamina Hulu Sanga Sanga9374
Pertamina Hulu Kalimantan Timur9013
Bumi Sakti Pusako (BSP)8240
Saka indonesia Pangkah Ltd7624
JOB Pertamina Medco Tomori Sulawesi7839
Petronas Carigali Ketapang Ltd7579
Husky-CNOOC Madura Ltd6421
All others612,712

Oil and gas production in Indonesia in 2022 is lower than in the previous year, nevertheless, the year 2022 has been quite an active and eventful year for the oil and gas industry in Indonesia. We saw several new platforms were installed and an old platform was decommissioned, many development wells were drilled, and many idle wells were reactivated.

Here are synopses of oil and gas production, field development, and exploration activities in Indonesia in 2022, and what we can expect to see in 2023, according to SKK Migas.

Oil and Gas Activities in Indonesia in 2022

Timpan 1 Well – Discovery well of Harbour Energy, Mubadala, and BP at offshore Aceh. Photo courtesy of Peter Bruce

Oil and gas production in Indonesia in 2022 is lower than in the previous year, nevertheless, the year 2022 has been quite an active and eventful year for the oil and gas industry in Indonesia. We saw several new platforms were installed and an old platform was decommissioned. Many development wells were drilled, and many idle wells were reactivated.   

Here are synopses of oil and gas production, field development, and exploration activities in Indonesia in 2022, and what we can expect to see in 2023, according to SKK Migas.

Oil Production

The average daily oil production in 2022 is 612,300 BOPD. This is below its 2022 target and also below the actual oil production in 2021. The oil production target for 2023 is 660,000 BOPD.

The top three oil producers are ExxonMobil Cepu Ltd., Pertamina Hulu Rokan, and Pertamina EP. Here are the top 15 oil producers in Indonesia in 2022.

Gas Production

The daily gas production in 2022 is 5,347,000 MMSCFD. This is below its 2022 target and also below the actual gas production in 2021. The gas production target is 6,160,000 MMSCFD in 2023.

Development Wells

Operators drilled 760 development wells in 2022. This is slightly below its target of 790 wells. However, it is a big increase from the number of development wells drilled in 2021. The target of development drilling in 2023 is 991 wells.

Workovers and well services

Oil and gas operators carried out 639 well workovers and 30,299 well services in 2022.

Reactivation of Idle Wells

As one of the strategies to increase oil and gas production, 968 idle wells were reactivated in 2022. The target of idle wells that will be reactivated in 2023 is set at 1086.

Investment

Investment in oil and gas projects in 2022 amounted to 12.3 billion USD. This is below its 2022 target but is higher than the amount of investment in 2021. The target of investment in 2023 is 15.5 billion USD.

Reserves Replacement Ratio (RRR)

With 890 million barrels of oil equivalent of reserves added in 2022, the ratio of reserves replacement in 2022 reaches 156%. This is higher than the RRR of 116% achieved in 2021. The target RRR for 2023 is 100%. The two biggest new reserves came from the Hidayah field development and the rejuvenation of the Sanga Sanga field.

The Hidayah field is located in the North Madura II work area and is operated by Petronas Carigali. It has estimated oil reserves of 88 million barrels of oil.

Exploration Drilling

Oil and gas operators in Indonesia drilled 30 exploration wells in 2022. This is higher than the 28 exploration wells drilled in 2021. The target of exploration drilling is set at 57 wells for 2023.

Twenty-two out of the twenty-seven completed exploration wells tested hydrocarbon. This represents an 81% success rate in exploration drilling.

Here are the 22 exploration wells that tested hydrocarbon in 2022.

2D Seismic Surveys

Oil and gas operators carried out 1950 KM of 2D seismic survey in 2022. This is below its target and the actual survey done in 2021. The target of the 2D seismic survey for 2023 is set at 1087 KM.

3D Seismic Surveys

3790 KM2 of the 3D seismic survey was conducted in 2022. This is below its target but higher than the actual survey done in 2021. The target of the 3D seismic survey for 2023 is set at 4602 KM2.

Unconventional Oil and Gas

Another strategy to increase oil and gas production in Indonesia is to explore the potential of unconventional oil and gas resources. Pertamina plans to drill two unconventional wells in 2023 in the Rokan work areas.

Strategic Oil and Gas Projects

Here are updates on the status of the 4 national strategic oil and gas projects.

1.           Jambaran Tiung Biru – Gas production from the two unitized fields of Jambaran and Tiung Biru came on stream on 20 September 2022. It is considered a strategic project as it will supply gas to industries in Central Java and East Java.

2.           Tangguh LNG train #3 – Train #3 of the Tangguh LNG plant is expected to come on stream in the first quarter of 2023.

3.           The IDD project – The Indonesia deepwater development project is in the process of changing partnerships and operatorship. 

4.           The Abadi Masela project – Pertamina is in the process of acquiring the interest of Shell in the project. The project is expected to be completed in 2029. 

Epilogue

As Indonesia is serious in its ambition to increase its oil and gas production, SKK Migas has set higher exploration and production targets for 2023. Also, the government has said that it will ratify the current oil and gas regulations to give stronger legal certainty to oil and gas investors and to attract more investments in 2023 and beyond.

We shall see an even more active and eventful year in 2023.

This article is adapted from the announcement made by SKK Migas on 18 January 2023. – Jamin Djuang

Countries with the Largest Oil Reserves in 2021

Photo courtesy of Rick Patenaude

The latest total oil reserves in the world amount to 1757 billion barrels.

This amount can last for 55 years assuming the daily global oil consumption of 97 million barrels per day.

Here are the world’s top 20 countries having the largest oil reserves in billions of barrels in 2021.

  1. Venezuela – 303.8
  2. Saudi Arabia – 258.6
  3. Iran – 208.6
  4. Canada – 170.3
  5. Iraq – 145
  6. Russia – 108
  7. Kuwait – 101.5
  8. United Arab Emirates – 97.8
  9. Libya – 48.4
  10. USA – 47.1
  11. Nigeria – 36.9
  12. Kazakhstan – 30
  13. China – 26
  14. Qatar – 25.2
  15. Brazil – 12.7
  16. Algeria – 12.2
  17. Ecuador – 8.3
  18. Norway – 8.1
  19. Angola – 7.8
  20. Azerbaijan – 7

Pertamina Geothermal Energy – The Maverick

The Lumut Balai geothermal power plant of Pertamina Geothermal Energy.

Pertamina Geothermal Energy (PGE) is a big and very active geothermal energy player in Indonesia. It is the operator of the first geothermal power plant in Indonesia – The Kamojang plant.

Engaging in thirteen geothermal work areas in Indonesia, PGE involves in the production of 1877 MW of geothermal power, 672 MW of which is under its operation and 1205 MW under the joint operation contracts.

PGE operates six of its solely owned geothermal plants and has interests in four other geothermal plants that are under a joint-operating contract scheme.

Pertamina Geothermal Energy has targets to increase its own power generation capacity from 672 MW to 1540 MW by 2030 contributing to reducing 9 million tons of CO2 emission annually.

As PGE aims to be a world-class green energy producer and to accelerate its ambitious geothermal expansion, it plans to launch an initial public offering (IPO) in the first quarter of 2023. The IPO has the potential to raise 500 million USD of new equity capital for the company.

Here are its current projects:

• Constructing the Lumut Balai 55 MW Unit 2 power station. Pertamina Geothermal Energy has commissioned the Mitsubishi Power consortium to construct its second 55-MW power station in the Lumut Balai work area in South Sumatra. When completed, the Lumut Balai geothermal plant will have an installed capacity of 110 MW.

• Completing a small-scale 500 KW geothermal power plant in Lahendong. This will serve as a model for small geothermal power plants to be built in other parts of the country.

• Recently PGE signed an MOU with Ormat Technologies to conduct a joint study on developing power plants using binary technology. CEO of PGE, Ahmad Yuniarto said that the application of binary technology has the potential to increase its current already installed generation capacity by up to 210 MW.

• PGE is exploring a partnership with Chevron targeting the utilization of geothermal energy for other purposes including such as green hydrogen production, CO2 processing, and extraction of rare metals.

• Pertamina Geothermal Energy sets out to expand its Ulubelu geothermal power plant located in Lampung, Indonesia. It plans to drill six wells in 2023. Currently, the Ulubelu power plant consisting of four power stations have a combined installed capacity of 220 MW. Pertamina is the operator of two of the power units while PLN is the operator of the other two power units.

The six geothermal plants that PGE operates are:

  1. Kamojang in West Java – 235 MW
  2. Ulubelu in Lampung, South Sumatera – 220 MW
  3. Lahendong in North Sulawesi – 120 MW
  4. Lumut Balai Unit 1 in South Sumatera – 55 MW
  5. Karaha in West Java – 30 MW
  6. Sibayak in North Sumatera– 12 MW

The Expanding Tangguh LNG

The Tangguh LNG Train #3 is under construction. Photo courtesy of Moch. Ali Masyhar.

The Government of Indonesia has granted a 20-year extension of the Tangguh production sharing contract (Tangguh PSC). Under the agreement, the Tangguh PSC which is due to expire in 2035, has been extended to 2055.

The Tangguh PSC covers three work areas. They are Berau, Muturi, and Wiriagar.

The partners under the Tangguh PSC are BP as the operator, MI Berau B.V., CNOOC Muturi Ltd., Nippon Oil Exploration (Berau) Ltd., KG Berau Petroleum Ltd., KG Wiriagar Petroleum Ltd., and Indonesia Natural Gas Resources Muturi Inc.

The 20-year contract extension is expected to generate 5 billion USD in revenues for the government of Indonesia.

Anja-Isabel Dotzenrath, BP’s EVP of Gas & Low Carbon Energy, said: “This extension reflects BP’s long-term commitment to Indonesia. It will allow us to continue to build on the great work that our Indonesia team has been doing with our partners and the strong support of the Government to deliver much-needed natural gas safely and reliably from Tangguh to Indonesia, and other markets. Today’s agreement will help open new possibilities for Tangguh’s future.”

The prolific Tangguh is currently the largest gas-producing work area in Indonesia, accounting for around 20% of the country’s gas output. It has generated significant revenues for Indonesia, both at the national government level and in both Papua Barat province and Teluk Bintuni regency where the project is located.

To process the produced natural gas, the Tangguh LNG was constructed in 2009. The plant has safely delivered more than 1,450 cargoes of LNG to both local and international markets.

Its two LNG production trains have a combined liquefaction capacity of 7.6 million tons of LNG a year.

A third LNG train is currently under construction and is expected to come online in 2023, increasing Tangguh’s production capacity by 50%. 

BP and its partners are also working on the Tangguh UCC project, for which the Government of Indonesia approved a Plan of Development in 2021. The project comprises the development of the Ubadari gas field, enhanced gas recovery (EGR) through carbon capture, utilization, and storage (CCUS) in the Vorwata field, and onshore compression.

BP has vast interests in Indonesia. As the operator of the Tangguh project, BP also has interests in the Andaman II block offshore Aceh and has recently signed new PSCs for Agung I and Agung II blocks. 


Source: BP Press Release on 23 December 2022

CCS Projects Around the World

We are seeing growing interests on the application of the CCS technologies to reduce carbon emissions around the world. CCS (Carbon Capture and Storage) is one of the ways to achieve net zero emissions.

Although CCS technologies have been around for many years, so far, there are only a few industrial plants that are equipped with CCS facilities. However, this is set to change as companies, especially oil and gas companies, begin to have serious interest in undertaking CCS and CCUS.

CCUS goes beyond CCS by utilizing the captured CO2 to achieve other purposes such as enhancing the recovery of hydrocarbon from the reservoirs.

Here are a few CCS and CCUS projects that are in the pipeline or being planned around the world.

JAPAN

Aiming at reducing the carbon emissions, Japan’s Ministry of Economy, Trade and Industry (METI) initiated the Tomakomai CCS Demonstration Project in 2012.

For this project, Japan CCS was commissioned to construct a CCS demonstration test plant in Tomakomai, Hokkaido, drill several injection wells, and construct a monitoring system to observe the behavior of CO2 and subsurface conditions after CO2 injection.

In April 2016, Japan CCS commenced injection of CO2 into a formation about 1,000 meters below the seabed.  In November 2019, the CO2 injection reached the target of 300,000 tonnes.

Following the injection, the company started Monitoring work that includes confirming that there is no CO2 seepage through monitoring the behavior of the injected CO2, constant monitoring of micro-seismicity and natural earthquakes, and conducting marine environmental surveys.

MALAYSIA

Petronas Carigali took FID (final investment decision) to develop the 3.3-million tonne/year carbon capture and storage (CCS) project at 3.2 TCF Kasawari sour gas field in Block SK316 offshore Sarawak, Malaysia.

The project, about 200 km off Bintulu, will capture and process CO2 from the field for injection into a depleted gas field.

THE UK

Phillips 66 in the UK is developing what could become the first-ever industrial-scale carbon capture project executed within a refinery at its affiliate’s 221,000 b/d Humber plant, with front-end engineering and design work awarded to Worley Ltd. expected to be complete by the end-2023.

NEW ZEALAND

New Zealand Energy has requested that the New Zealand oil and gas regulator, New Zealand Petroleum and Minerals, amend petroleum mining licenses 38140 (Waihapa) and 38141 (Ngaere) to allow for carbon sequestration.

INDONESIA

ExxonMobil and Pertamina signed a Heads of Agreement to further progress their regional carbon capture and storage hub (CCS) for domestic and international CO2.

The agreement defines the next steps for the project offshore Java—where the companies estimate geologic storage potential of up to 3 billion metric tons—including concept-select, pre-front-end engineering design, and a subsurface work program.

PEMA (PT Pembangunan Aceh) recently formed a joint-venture company, PT Carbon Aceh, to repurpose the now-depleted giant Arun field gas reservoir offering open-access storage of CO2 in 2029.

BP Indonesia has opened a pre-qualification tender for the provision of onshore front-end engineering and design (FEED) services for a carbon capture and storage (CCS) project at its Tangguh liquefied natural gas (LNG) complex in Indonesia.

BP and its Tangguh LNG partners today confirmed that Indonesian oil and gas regulator SKK Migas has approved the plan of development (POD) for a key carbon capture utilization and storage (CCUS) project at the Tangguh LNG export complex.

BP said this CCUS project will make Tangguh one of the lowest greenhouse gasses (GHG) intensity LNG plants in the world.

The scope of the Tangguh CCUS project includes the utilization of the separated CO2. The CO2 separated from the incoming natural gas will be reinjected back to the Vorwata gas reservoir for sequestration and enhanced gas recovery. The total emissions reduction is up to 25 million tonnes of CO2 equivalent by 2035.

AUSTRALIA

British Petroleum has entered into a non-binding agreement with Santos that will lead to BP investing in Santos’ Moomba carbon capture and storage (CCS) project in South Australia.

The carbon dioxide that is separated from natural gas will be captured at the Moomba gas processing plant and reinjected into the geological formations of the Cooper Basin. This will aim to capture 1.7 million tonnes of carbon dioxide each year.

The Cooper Basin’s reinjection capacity has been assessed at up to 20 million tonnes of carbon dioxide per year, for 50 years. This has the potential to be a large-scale carbon sink for power generators and other industries in Australia.

SINGAPORE

Chevron through its Chevron New Energies International subsidiary, and Mitsui O.S.K. Lines (MOL) will explore the technical and commercial feasibility of transporting liquified CO2 from Singapore to permanent storage sites offshore Australia.

“Developing safe and reliable CO2 transportation services is a crucial step in developing large-scale Carbon Capture, Utilization, and Storage (CCUS) solutions, said Mark Ross, president of Chevron Shipping Co.

THE US

BP and Linde recently announced plans to advance a major carbon capture and storage (CCS) project in Texas that will enable low-carbon hydrogen production at Linde’s existing facilities. The development will also support the storage of carbon dioxide (CO2) captured from other industrial facilities – paving the way for large-scale decarbonization of the Texas Gulf Coast industrial corridor.

Upon completion, the project will capture and store CO2 from Linde’s hydrogen production facilities in the greater Houston area – and potentially from its other Texas facilities – to produce low-carbon hydrogen for the region. The low-carbon hydrogen will be sold to customers along Linde’s hydrogen pipeline network under long-term contracts to enable the production of low-carbon chemicals and fuels.

This article is adapted by LDI Training from various sources.

The Super Giant Arun Gas Field

The monument showing the location of the first well of the Arun gas field.

About The Unique Arun Gas Field

The Arun field is a supergiant gas field. It had 16 trillion cubic feet of original gas in place and was discovered in 1971 by Mobil Oil in Aceh, Sumatra.

Interestingly, the gas concession was initially held by Asamera. Due to unsuccessful exploration by Asamera, it was sold to Mobil Oil in 1968.

The Arun gas reservoir had abnormally high temperatures and pressure of 178 degrees C and 7100 PSIG respectively. The reservoir is made up of carbonate rock located at 10,000 feet in depth.

Due to its high pressure, porosity, permeability, and reservoir thickness of about 500 feet, the Arun gas wells were extremely productive. Each well could produce more than 100 MMSCF of gas per day.

The highly prolific Arun field produced over 3000 MMSCF of gas per day from its 78 wells for more than 10 years. The produced natural gas was fed into the Arun LNG plant to recover the condensate and liquefy the gas.

The field is estimated to have produced over 14 trillion cubic feet of natural gas and 840 million barrels of condensate.

As a retrograde gas reservoir with no water drive, Mobil Oil took extreme care to manage the reservoir to achieve the highest gas recovery possible. Steps, such as gas reinjection, were taken to manage the reservoir pressure. Up to 900 MMSCF of dry gas were injected back into the reservoir daily through 11 injection wells.

As the reservoir and wellhead pressures eventually declined, gas compressors were used to boost gas production.   

By 2014, the Arun field gas production had become so low that the LNG plant was shut down permanently.

The now depleted and low-pressure Arun gas reservoir is a great candidate for storing captured CO2 as it is a volumetric reservoir meaning the reservoir is completely sealed. It is enclosed by impermeable barriers that prevent any fluid from entering or leaving the reservoir.

The Arun LNG Plant

The Arun LNG plant was built to monetize the huge amount of the discovered gas. It is the first LNG plant built in Indonesia and Southeast Asia.

Initially, the Arun LNG plant consisted of three LNG trains that started to operate in August 1978, September 1978, and February 1979 respectively.

Two trains were later added to the plant in October 1983 and January 1984 respectively.

All five trains produced a total of 55,000 M3 per day of LNG and 115,000 barrels per day of condensate.

The LNG plant eventually had six trains. The sixth train was completed in November 1984.

Up till 1999, Indonesia produced one-third of the LNG in the world.

A major problem in processing Arun gas is that the gas has a large percentage of mercury and it reacts with aluminium in the cryogenic system to form an amalgam.

After 36 years in operation, the Arun LNG plant was finally shut down in 2014.

The Gas Well Blowouts

The massive blowout in the Arun field happened in 1978 when the CII-2 well in the Arun field was being drilled.

The blowout killing efforts were led by Red Adair. Initially, the well control team attempted to kill the well from the top.  However, it failed.

Finally, the blowout was killed by drilling a directional well and then pumping a huge amount of acid followed by heavy mud into the bottom of the CII-2 well.

The blowout was so huge and due to the extremely high reservoir pressure, more than fifty high-pressure and high-volume mud pumps, and more than one hundred pump operators and engineers were brought in from several countries to kill the blowout.

Another Arun well, CIII-8, blew out two years later in 1980.

The Ambitious Arun CCS Project

Although the huge Arun field reservoir has been almost completely depleted for some time, it may have a second life.

As the world is committed to reducing carbon emissions by capturing emitted CO2, the Arun field has a huge potential to become the largest storage facility for captured carbon in Asia.  

PEMA (Pembangunan Aceh) has formed a joint venture company, Carbon Aceh, to perform a feasibility study up to the development, implementation, and operation of the Arun CCS project which is planned to start operating in 2029.

The depleted Arun gas reservoir is a perfect candidate for storing CO2 for the following reasons:

  • It is almost completely depleted and therefore it has low pressure.
  • It is completely enclosed and therefore the storage space is completely sealed.
  • It has an enormous volume of storage space. It can store more than 1 billion metric tonnes of CO2.

Moreover, the Arun field already has infrastructure that can be used to facilitate the CCS project such as offshore terminals that can receive CO2 shipments from CO2 tankers and pipelines that can transport the CO2 to the Arun field.

Marzuki Daham, former Chairman of BPMA – Aceh Oil & Gas Regulatory Body – gave his comment on this important CCS project.

“A great location with the existing infrastructure will surely be a plus to support the project. It would be even more interesting if Arun can be an open-access storage for captured CO2 from many countries around the area. It is a step to save the planet.”

When the Arun carbon storage facility becomes operational, the Arun field will be known not just as one of the largest gas fields and LNG plants in the world, but it will also be known as one of the largest carbon storage facilities in the world.

This article is adapted from various sources by Jamin Djuang – Chief Learning Officer of LDI Training and author of “The Story of Oil and Gas – How Oil and Gas are Explored, Drilled and Produced”.

Oil and Gas Activities in Indonesia in Third Quarter 2022


The oil and gas industry of Indonesia has been active and alive in the first nine months of 2022, and it expects to up the tempo of its exploration and production activities as it marches toward the year-end.

Here is the summary of oil and gas activities in Indonesia at the end of the third quarter of 2022 according to a report published by SKK Migas.

DEVELOPMENT WELL DRILLING

Oil and gas operators in Indonesia drilled 545 development wells in the first three quarters of 2022.

The head of SKK Migas, Mr. Dwi Soetjipto, said that the number of development wells drilled by the end of the third quarter of 2022 has exceeded the number of wells drilled in 2021.

To meet the daily oil and gas production targets, it has increased the target of the number of development wells in 2022 from 790 to 801.

EXPLORATION DRILLING

Oil and gas operators drilled 21 exploration wells in the first three quarters. This is the same number of exploration wells drilled in the same period in 2021.

WELL INTERVENTION

Oil operators carried out 495 workovers in the first three quarters. This number is 87% of the 2022 workover target.

At the same time, well service operations also took place at a high tempo. Companies carried out more than 22000 well service operations. This number represents 99% of the 2022 target.

OIL AND GAS PRODUCTION

Here is the daily oil and gas production at the end of September 2022.
Oil – 613,000 BOPD
Gas – 5,353,000 MMSCFD

The combined daily oil and gas production is 1,562,000 BOEPD. This number is around 90% of the 2022 target.

As most of the oil and gas fields are very old, while operators are drilling wells to increase production, they also are experiencing high rates of natural decline.

STATE REVENUES FROM OIL AND GAS

The oil industry contributed USD 13.95 billion or IDR 202 trillion to the coffers of the government of Indonesia in the first nine months of 2022.

In just 9 months, this amount has exceeded the entire 2022 target of the state revenues from oil and gas by 40% due to the high prices of oil.

RESERVE REPLACEMENT

The oil and gas reserve replacement ratio (RRR) reaches 97.5% of the 2022 target.

SKK Migas expects the RRR will reach 186% of the 2022 target by the end of this year as several plan of development (POD) will be approved.

The RRR realized in the past five years has been greater than 100% of the target.

MULTIPLIER EFFECTS OF OIL AND GAS OPERATIONS

The oil and gas industry activities create positive and significant multiplier effects to the economy of Indonesia besides generating substantial revenues to the government.

The value of the components produced domestically in oil equipment and services sold amounts to USD 2.9 billion or IDR 42 trillion.

TKDN (Tingkat Komponen Dalam Negeri), the percentage of domestic components or services in products, reaches nearly 64%.

SKK Migas is actively encouraging and promoting national entrepreneurs and equipment manufacturers to meet the needs of the oil and gas industry.

ONE-DOOR SERVICE POLICY

The One Door Service Policy (ODSP) of SKK Migas has been very instrumental in getting permits and licenses approved quickly.

The average licensing process period has been sharply reduced to about 1 day from 14 days before the ODSP policy was introduced.

SKK Migas is committed to making it easy for oil operators to carry out their exploration and production activities as it continues to encourage massive and aggressive efforts by oil operators to increase their oil and gas production.


This article is adapted by Jamin Djuang from a recent article published by SKK Migas – The Special Task Force for Upstream Oil and Gas Business Activities of Indonesia.

Top Oil and Gas Operators in Indonesia in 2022

Production and drilling operations at the Bekapai field of Pertamina Hulu Mahakam

Here are the fifteen oil and gas operators in Indonesia with significant production volume and the potential to increase them, according to SKK Migas.

  • BP Berau
  • Eni East Sepinggan
  • Exxon Mobil Cepu 
  • Husky-CNOOC Madura
  • Medco E&P Grissik
  • PetroChina International Jabung
  • Premier Oil Natuna Sea B.V.
  • Pertamina EP
  • Pertamina Hulu Energi Jambi Merang
  • Pertamina Hulu Energi ONWJ
  • Pertamina Hulu Energi OSES
  • Pertamina Hulu Kalimantan Timur
  • Pertamina Hulu Mahakam
  • Pertamina Hulu Rokan 
  • Pertamina Hulu Sanga Sanga

This post is adapted by LDI Training from information posted by SKK Migas, the oil and gas regulator of Indonesia.

The Humongous Well Blowout of Arun Field

The biggest gas well blowout in Indonesia happened in 1978 when the CII-2 well in the Arun field was being drilled. This blowout is also the biggest in Southeast Asia ever.

About The Super Giant Arun Gas Field

The Arun field is a supergiant gas field. It had 16 trillion cubic feet of original gas in place and was discovered in 1971 by Mobil Oil in Aceh, Sumatra.

The Arun gas reservoir had abnormally high temperatures and pressure of 178 degrees C and 7100 PSIG respectively. The reservoir is made up of carbonate rock located at 10,000 feet in depth.

Due to its high pressure, porosity, permeability, and reservoir thickness of about 500 feet, the Arun gas wells were extremely productive. Each well could produce more than 100 MMSCF of gas per day.

The highly productive Arun field produced over 3000 MMSCF of gas per day for more than 10 years. The produced natural gas was fed into the Arun LNG plant to recover the condensate and liquefy the gas.

The field is estimated to have produced over 14 trillion cubic feet of natural gas and 840 million barrels of condensate.

As a retrograde gas reservoir with no water drive, Mobil Oil took extreme care to manage the reservoir to achieve the highest gas recovery possible. Steps, such as gas reinjection, were taken to manage the reservoir pressure. As the reservoir and wellhead pressures eventually declined, gas compressors were used to boost gas production.   

The now-depleted Arun reservoir is a great candidate for storing captured CO2 as it has no water influx and is at low pressure.

The Arun LNG Plant

The Arun LNG plant was built to monetize the huge amount of the discovered gas. It is the first LNG plant built in Indonesia and Southeast Asia.

Initially, the Arun LNG plant consisted of three LNG trains that started to operate in August 1978, September 1978, and February 1979 respectively.

Two trains were later added to the plant in October 1983 and January 1984 respectively.

All five trains produced a total of 55,000 M3 per day of LNG and 115,000 barrels per day of condensate.

The LNG plant eventually had six trains. The sixth train was completed in November 1984.

Up till 1999, Indonesia produced one-third of the LNG in the world.

A major problem in processing Arun gas is that the gas has a large percentage of mercury reacts with aluminium in the cryogenic system to form an amalgam.

After 36 years in operation, the Arun LNG plant was finally shut down in 2014.

The Gas Well Blowout

The massive blowout in the Arun field happened in 1978 when the CII-2 well in the Arun field was being drilled.

The blowout killing efforts were led by Red Adair. Initially, the well control team attempted to kill the well from the top.  However, it failed.

Finally, the blowout was killed by drilling a directional well and then pumping a huge amount of acid followed by heavy mud into the bottom of the CII-2 well.

The blowout was so huge and due to the extremely high reservoir pressure, more than fifty high-pressure and high-volume pumps, and one hundred pump operators and engineers were brought in from several countries to kill it.

The photo above, courtesy of Pete Hackney, showed another Arun well, CIII-8, that blew out two years later in 1980. You can see the rig drilling a directional well that would intersect the blowing-out well to kill it.

Oil and Gas Activities in Indonesia in May – June 2022

A pumping well of Pertamina. Photo courtesy of Pertamina

Here is the monthly summary of oil and gas exploration and production activities in Indonesia in May 2022, according to SKK Migas.

·     Daily crude oil production: 616,800 BOPD
·     Daily gas production: 5321 MMSCFD
·     Daily oil and gas production: 1,567,000 BOEPD
·     Exploration wells drilled YTD: 11
·     Development wells drilled YTD: 291
·     2-D seismic survey completed YTD: 559 KM
·     3-D seismic survey completed YTD: 269 KM2
·     Amount of investment YTD: USD 3.9 billion
·     Number of Work Areas: 170

Here are other recent happenings in the oil patch of Indonesia.

·     Pertamina recorded $2.046 billion corporate profit in 2021. This almost doubles the profit it made in 2020. 
·     Pertamina EP has completed the construction of the Beringin A gathering station in Muara Enim in South Sumatera. The gathering station is designed to increase the capacity of the Prabumulih field to handle an additional 15 million MMSCFD of gas and 382 BPD of condensate.  
·     Pertamina Hulu Energy has made hydrocarbon discovery from its exploration well GQX-1 in the Offshore North West Java (ONWJ) work area.
·     Gas production from the newly completed JML1 platform in the Jumelai field operated by Pertamina Hulu Mahakam had come on stream. The gas is piped to the production facility of the Senipah-Peciko-South Mahakam field. The Jumelai project is expected to produce 45 MMSCFD of gas and 710 BPD of condensate.
·     PT BSP (Bumi Siak Pusako) has started drilling its exploration well Nuri-1X in the CPP (Corridor Plain and Pekanbaru) Block in Riau. The company plans to drill 15 development wells and two exploration wells in 2022.
·     Pertamina Hulu Energy has started drilling the exploration well NSO-R2 in the North Sumatera Offshore work area.
·     Gas production from the new platform WPS-3 of Pertamina Hulu Mahakam came on stream on 10 June 2022. The installation of the WPS-3 platform and the subsequent drilling of the development wells are part of the JSN (Jumelai, North Sisi, and North Nubi) project. This platform is designed to handle 45 MMSCFD of gas.

This article is curated by Jamin Djuang, Chief Learning Officer of LDI Training.

High Potential Individuals

Stanford University Campus – Photo courtesy of Pexels – Zetong Li

Do you want to be a “high potential individual”? The secret lies in having a good education.

Education is a great social equalizer. A good education can level the playing field for everyone, especially disadvantaged people. Education can open more and better opportunities for them in the future and provide the chance for them to work and live in the places of their dream.

Indeed, the UK government has just announced it is inviting “high potential individuals” to apply to work and live in the UK.

You are considered a “high potential individual” by the UK Government if you are a recent graduate from the world’s top 37 universities outside of the UK. These are universities outside the UK that appeared at least twice in the Top 50 rankings in 2021.

So, you are a “high potential individual” if you are a recent graduate from the following 37 universities located outside the UK:

  • California Institute of Technology (Caltech) — U.S.
  • Chinese University of Hong Kong (CUHK) — Hong Kong
  • Columbia University — U.S.
  • Cornell University — U.S.
  • Duke University — U.S.
  • Ecole Polytechnique Fédérale de Lausanne (EPFL Switzerland) — Switzerland
  • ETH Zurich (Swiss Federal Institute of Technology) — Switzerland
  • Harvard University — U.S.
  • Johns Hopkins University — U.S.
  • Karolinska Institute — Sweden
  • Kyoto University — Japan
  • Massachusetts Institute of Technology (MIT) — U.S.
  • McGill University — Canada
  • Nanyang Technological University (NTU) — Singapore
  • National University of Singapore — Singapore
  • New York University (NYU) — U.S.
  • Northwestern University — USA
  • Paris Sciences et Lettres – PSL Research University — France
  • Peking University — China
  • Princeton University —  U.S.
  • Stanford University — U.S.
  • Tsinghua University — China
  • University of British Columbia — Canada
  • University of California, Berkeley — U.S.
  • The University of California, Los Angeles (UCLA) — U.S.
  • University of California, San Diego — U.S.
  • University of Chicago US — U.S.
  • University of Hong Kong — Hong Kong
  • University of Melbourne — Australia
  • University of Michigan-Ann Arbor — U.S.
  • University of Munich (LMU Munich) — Germany
  • University of Pennsylvania — U.S.
  • The University of Texas at Austin —  U.S.
  • University of Tokyo — Japan
  • University of Toronto — Canada
  • University of Washington — U.S.
  • Yale University — U.S.

Now we know why everyone wants to go to the best universities in the world.

The Bekapai – From an oil field to a gas field

The Bekapai field underwent Phase 2B Expansion. Photo from Pertamina.

THE DISCOVERY

In 2022, the Bekapai oil field, located offshore of the Mahakam Delta in East Kalimantan in Indonesia, celebrates its 50th anniversary.

The Bekapai field was discovered in April 1972 by Total along with its partner, Japex.

The field was almost undiscovered had Total’s exploration team given up its exploration drilling campaign after drilling six dry wells.

With the discovery of the Bekapai field, Total Indonesie went on to discover many big oil and gas fields in the Mahakam block – Tunu, Sisi-Nubi, Tambora, Handil, and Peciko.

Although the Bekapai is not as big as the other fields in the Mahakam block, the Bekapai field is the most well-known field in the Mahakam block being the first oil field that was discovered by Total Indonesie in East Kalimantan. A nice park in Balikpapan is named after Bekapai – Bekapai Park.

FIELD DEVELOPMENT AND PRODUCTION

The reservoirs of the Bekapai field are described as complex multi-layered reservoirs.

Total Indonesie constructed ten platforms and drilled 74 development wells between 1974 and 1996.

The Bekapai field began as an oil field. Oil production started in 1974 with peak production at around 60,000 BOPD in 1978. Then its oil production declined slowly until it reached around 1,000 BOPD in 2007.

As its oil production reached its lowest level, to rejuvenate its oil and gas production the field underwent several redevelopment and transformation projects.

FIELD EXPANSION AND TRANSFORMATION

Phase 1 Expansion

Total Indonesie initiated the Phase 1 field expansion project in 2008. The company drilled 9 development wells and production increased to 10,000 BOPD and 46 MMSCFD of gas by 2013.

With the success achieved in Phase 1 Expansion, the company conducted a 3D seismic survey to assess the potential of the Bekapai field for further development.

Phase 2A Expansion

Based on the encouraging seismic results, the company embarked on the Phase 2A expansion project to further develop the Bekapai Field.

The company drilled two development wells in 2014 and its oil production increased to 11,500 BOPD. This is a record oil production rate of the Bekapai field in its first 25 years of production.

Phase 2B Expansion

As the oil reserves of the Bekapai are depleted, Total’s engineers turn their attention to producing its gas.

The objective of Phase 2B Expansion is to produce the so-far untapped gas accumulation in the Bekapai reservoirs. The plan is to increase the capacity of the field to produce 100 MMSCFD of gas.

Here were what was involved in the Phase 2B Expansion Project.

  • Produced the gas remaining in the gas caps.
  • Increased the capacity of the offshore production facilities to produce 100 MMSCFD of gas.
  • Platform modifications
  • Constructing a 12,6 km long submarine 12-inch pipeline from the Bekapai field to the Peciko field.

Phase 2B Expansion transformed the Bekapai field from an oil field to a gas field. The project increased the gas production of the Bekapai field from around 40 MMSCFD to 92 MMSCFD in 2015, making it a significant gas contributor to LNG production.

Phase 3 Expansion

Pertamina Hulu Mahakam as the new operator continues to further tap the gas potentials of the Bekapai field under the Phase 3 Expansion.

This ongoing expansion project involves modifying the manifold wellhead platforms BH and BE to accommodate 5 new development wells.

This project is expected to produce an additional 27 MMSCFD of gas when it is completed in November 2022.

POSTLUDE

On January 2, 2018, Pertamina Hulu Mahakam became the operator of the Bekapai field and all the fields in the Mahakam block.

Pertamina Hulu Mahakam maintains the spirit of innovation and continues to develop the remaining potential of the 50-year-old oil field.

Pertamina Hulu Mahakam managed to reach ten years without LTI (Lost Time Injury) on August 27, 2021.

And finally, with the saying “An old oil field never dies”, may the Bekapai field continues to find a new life.

Oil and Gas Projects in Indonesia in 2022

Sail away from Bintan to East Kalimantan of two topsides for North Sisi and North Nubi fields of Pertamina Hulu Mahakam on 4 November 2021.

Oil and gas operators in Indonesia are investing USD 1.35 billion to expand and further develop their existing fields to increase their oil and gas production in 2022.

Here are the 12 oil and gas field expansion and development projects earmarked by SKK Migas to produce additional 19,000 barrels per day of oil and 567 MMSCFD of gas in Indonesia in 2022.

Bukit Tua Phase 2B Development At Offshore East Java

Operator: Petronas Carigali Ketapang II Ltd

Production Target: 14000 BOPD and 30 MMSCFD

Scope of work: Installation of Platform BTJT-B and drilling of development wells.

Completion date: 12 April 2022 (Completed)

Investment:  US$ 117 million

Hiu Gas Field Phase 2 development at Block B Natuna

Operator: Medco E&P Natuna

Scope of work: Drilling two development wells Hiu A05 and Hiu A06

Target of production: 49 MMSCFD of gas

Investment: 45 million USD

Expected date of completion: May 2022

Jumelai Field Development in East Kalimantan

Operator: Pertamina Hulu Mahakam

Scope of work: Installation of platform JML1 and drilling of development wells

Production target: 45 MMSCFD of gas

Completion date: May 2022

Investment: US$ 65 million

Baru Gas Plant Modification in Riau

Operator: Energi Mega Persada (EMP Bentu)

Scope of work: Gas plant modification and suppling 30 MMSCFD of gas to Tenayan power plant of PLN

Expected date of completion: May 2022

Investment: 13.5 million USD

South Sembakung Production Facility Expansion in East Kalimantan

Operator: JOB PMEPS – Joint Operation Body of Pertamina and Medco EP Simenggaris

Target of production increase: 30 MMSCFD of gas

Expected completion date: June 2022

Investment: 9,2 million USD

Development of MDA and MBH fields at offshore Madura

Operator: Husky CNOOC Madura Ltd (HCML)

Scope of work: Drilling of 5 wells at MDA field and 2 wells at MBH field to supply gas to the East Java Gas Pipeline.

Target of production increase: A total of 175 MMscfd of gas from MBH in May 2022 and MDA in July 2022.

Total investment: 625 Million USD

Belida Gas Field Extension at Block B Natuna

Operator: Medco E&P Natuna

Target of production: 40 MMSCFD of gas

Investment: 78 Million USD

Expected date of completion: August 2022

Tanjung Field Polymer Flood

Operator: Pertamina EP in South Kalimantan

Scope of work: Full-scale polymer flooding

Target: Increasing oil production and oil recovery factor

Expected date of completion: September 2022

Investment: 19 million USD

MAC Field Development in Offshore Madura

Operator: Husky CNOOC Madura Ltd (HCML)

Scope of work: Installation of a platform and pipelines, and drilling of development wells

Target of production: 60 MMSCFD of gas

Expected date of completion: October 2022

Investment: 163 Million USD

North Sisi and North Nubi Development in East Kalimantan

Operator: Pertamina Hulu Mahakam

Scope of work: Installation of Platform WPS3 at North Sisi and Platform WPN4 at North Nubi, and drilling of development wells.

Production Target: A total of 90 MMSCFD

Expected Completion date: Second half of 2022

Investment: US$ 133 million

Bekapai Field Phase 3 Expansion

Operator: Pertamina Hulu Mahakam

Scope of work: Modification of Manifold Wellhead Platform BH and BE to accommodate 5 new development wells.

Production target: 27 MMscfd

Completion date:  November 2022

Investment: US$ 28 million

YY Field Redevelopment at Offshore North West Java

Operator: Pertamina Hulu Energi ONWJ

Project scope: Relocating the wellhead platform due to the blowout of well YYA-1 in 2019

Target of production increase: 2000 BOPD and 1 MMSCFD of gas

Date of Completion: December 2022

Investment: 56.4 Million USD

This article is curated by Jamin Djuang, Chief Learning Officer of LDI Training, based on information provided by SKK Migas and other sources.

Oil and Gas Projects of Indonesia in 2021

The North Processing Unit of Pertamina Hulu Mahakam by the Mahakam River. Photo courtesy of Pertamina Hulu Mahakam.

Oil operators in Indonesia completed 15 projects that were targeted to increase oil and gas production in 2021, according to SKK Migas.

Here are the 15 projects completed in 2021 that generated additional 18,500 barrels of oil and 746 MMSCF of gas per day:


·      Gas Compression at Lematang – Medco E&P Lematang


·      Non- associated gas compression at West Betara – PetroChina Jabung


·      Gas Pipeline to Balikpapan Refinery – Pertamina Hulu Mahakam


·      Merakes Deep-water Gas Field Development – Eni East Sepinggan


·      Gas Production at South Jambi B – Jindi South Jambi Block B Co


·      Early Production Facility at Belato field – Seleraya Merangin Dua


·      Gathering Station Akasia Bagus at Jatibarang field – Pertamina EP


·      Sidayu Field Development – Saka Indonesia Pangkah 


·      West Pangkah Field Development – Saka Indonesia Pangkah


·      EOR of the Jirak Structure at Pendopo Field – Pertamina EP


·      Development Well Drilling – Bambu Besar Field of Pertamina EP


·      Field development – The KLD field of Pertamina Hulu Energi ONWJ


·      Gathering Station Upgrade at Bangadua Field – Pertamina EP Jatibarang


·      Construction of a new Oil Plant – Semberah Field of Pertamina Hulu Sanga Sanga


·      Debottlenecking of Jangkrik Floating Production Unit – Eni Muara Bakau

In 2022, oil companies plan to invest USD 1.35 billion in 12 projects that will add 19,000 BOPD and 567 MMSCFD of gas.

LDI Training

Data Science in Oil and Gas

Photo by Vitaly Vlasov from Pexels

Firstly, what is Data Science?

Data science is using analysis of past and current data to predict future performance or results.

Oil and gas companies collect a huge amount of data in their exploration, drilling, and production activities. They have huge volumes of unused and undervalued data.

With the advances in data science and machine learning, oil companies have begun to realize the value of the data they have been collecting.

They now realise that managing this data and using it as a strategic asset can significantly impact its operational success, increase safety and reduce operational cost.

For example, in exploration, seismic data and geological data, such as rock types in nearby wells, can be used to predict oil pockets.

In production, production data can be used to forecast future production capacity, schedule production, and determine the number of future wells to be drilled.

In drilling, engineers can use drilling data to determine the best drilling locations, reduce costs, improve safety and shorten the drilling time.

Here are several articles by Yohanes Nuwara on the applications of data science and machine learning in oil and gas operations.

ML sonic log prediction in Volve field – https://towardsdatascience.com/prediction-of-p-sonic-log-in-the-volve-oil-field-using-machine-learning-9a4afdb92fe8

ML prediction in hydraulic fracturing – https://medium.com/analytics-vidhya/machine-learning-for-prediction-in-hydraulic-fracturing-43de92b0e10a

ML lithology prediction from drilling data – https://towardsdatascience.com/oilfield-lithology-prediction-from-drilling-data-with-machine-learning-520ee9ff6e7c

Rate of penetration optimization using Particle Swarm Optimization – https://towardsdatascience.com/faster-drilling-with-machine-learning-and-particle-swarm-optimization-335bb28d687

As the Oil and Gas industry grows and becomes receptive to big data and the use of Data Science, it can only move forward. 

If you want to learn how to use Data Science and its applications, Yohanes Nuwara will teach “DATA SCIENCE AND MACHINE LEARNING IN OIL AND GAS” on May 7, 11, 14, 18, and 21, 2022.

The Moment of Truth of Oil Exploration – The DST

A successful DST Test in East Kalimantan, Indonesia – Photo courtesy of Rick Patenaude

Drill-stem testing (DST) in exploration wells is the last step of oil and gas exploration. It is the moment of truth in the quest for the elusive oil and gas.

Witnessing a drill-stem test can be daunting as the company has invested a lot of time and money to find a new oil or gas field. As DST results can move the company’s share prices, during the test, the test results can only be communicated to a few people back in the company headquarters.

I have witnessed both successful DST and unsuccessful DST.

Here are the five moments of truth of a DST in exploration wells.

The first moment of truth is after the DST valve is open, you begin to see air bubbles showing up in a bucket of water that is placed on the rig floor. As the air bubbles become stronger, you know something is coming out from the test interval.

The second moment of truth is when you see the fire at the burner. When you see the flare, it confirms you have found hydrocarbon.

The third moment of truth is when we know the flow rates of the hydrocarbon fluids that come out from the well.

The fourth moment of truth is after you have measured the initial bottomhole shut-in pressure and the final shut-in bottomhole pressure. Reservoir engineers will love these two pressures to be about the same. If the final BHSI pressure is much lower than the initial BHSI pressure, it may indicate the reservoir is quite small.

The fifth moment of truth is when you know the fluid composition when you receive the fluid analysis report from the laboratory. This last moment of truth may kill all the prior excitements during a DST.

Here is to illustrate the significance and implications of the composition of the reservoir fluid.

In 1973, AGIP discovered the huge East Natuna gas field off northern Natuna Island of Indonesia. However, as the gas contains a very large percentage of CO2 – 71% – the huge gas field is still undeveloped today.

Finally, perhaps the best moment of truth in a DST is when a difficult and high-risk test, such as testing a high pressure or high H2S well, is completed successfully and safely, and the people involved in the test can leave the rig with a sense of accomplishment.

This article is written by Jamin Djuang, the author of The Story of Oil and Gas: How Oil and Gas Are Explored, Drilled and Produced.

Oil Fields in Indonesia with EOR Potential

A jetty at Balikpapan Refinery – Photo shared by Zaldi Ansyah

In the efforts to increase the oil production of Indonesia, the government has identified 34 oil fields as candidates having potentials for enhanced oil recovery.

Here are the fields and their locations:

  • Rantau field – Aceh
  • Bangko field – Rokan Block
  • Bekasap field – Rokan Block
  • Kulim field – Rokan Block
  • Balam South field – Rokan Block
  • Petani field – Rokan Block
  • Pematang field – Rokan block
  • Zamrud field – Coastal Plain and Pekanbaru (CPP) block
  • Beruk field – CPP block
  • Pedada field – CPP block
  • Pusak field – CPP block
  • Sago field – Pertamina EP Asset 1 Jambi
  • Ramba field – Pertamina EP Asset 1 Jambi
  • Limau Q51 field – Pertamina EP Asset 2 South Sumatera – Limau
  • Jirak field – Pertamina EP Asset 2 South Sumatera – Limau
  • Belida field – Natuna D Alpha block
  • Melibur field – Siak, Riau
  • Gemah field – Jambi, South Sumatera
  • Makmur field – Jambi, South Sumatera
  • Kaji field – Rimau block
  • Semoga field – Rimau block
  • Iliran High field – Rimau block
  • Rama field – South East Sumatera (SES) block
  • Krisna field – SES block
  • Widuri field – SES block
  • E-main field – Offshore North West Java (ONWJ)
  • Zulu field – ONWJ
  • MQ field – ONWJ
  • Jatibarang field – Pertamina EP Asset 3 in West Java
  • Mudi field – Pertamina EP Asset 4 in East Java
  • Sukowati field – Pertamina EP Asset 4 in East Java
  • Tanjung field – Pertamina EP Asset 5 in Kalimantan
  • Handil field – Mahakam block
  • Gundih field – Central Java

How Strong Is Your Self-Leadership

ASSESSING YOUR SELF-LEADERSHIP STRENGTH

There is a saying that before you can lead others, you must first lead yourself. In other words, it is not possible to lead others if you cannot lead yourself.

Do you know how strong is your self-leadership?

Here is a quick and simple self-test to assess your self-leadership strengths and discover your weaknesses and opportunities for self-improvement.

Circle YES if you possess and demonstrate the following self-leadership qualities according to McKinsey and Company.

ON SELF-AWARENESS AND SELF-MANAGEMENT

  • Understanding own emotions and triggers. Yes / No 
  • Self-control and regulation. Yes / No
  • Understanding own strengths. Yes / No
  • Integrity. Yes / No
  • Self-motivation and wellness. Yes / No
  • Self-confidence. Yes / No

ON ENTREPRENEURSHIP

  • Courage and risk-taking. Yes / No
  • Driving change and innovation. Yes / No
  • Energy, passion, and optimism. Yes / No
  • Breaking orthodoxies. Yes / No

ON GOALS ACHIEVEMENT

  • Ownership and decisiveness. Yes / No
  • Achievement orientation. Yes / No
  • Grit and persistence. Yes / No
  • Coping with uncertainty. Yes / No
  • Self-development. Yes / No

SCORING AND ASSESSMENT

Count the number of YES that you circle.

If your score is high, congratulations! It means you have many of the qualities of strong self-leadership and good self-management.

If your score is not high, you can improve your self-leadership by knowing the qualities you are lacking and embracing the right values that will enhance your self-leadership and self-discipline. 

Here are inspiring quotes from Oprah Winfrey.

“It doesn’t matter who you are, where you came from. The ability to triumph begins with you. Always.”

Finally, to be a leader, you must have integrity. All your efforts will go to nothing if you don’t have it.

“Real integrity is doing the right thing, knowing that nobody’s going to know whether you did it or not.”